Selective interval packer



June 30, 1970 R. c. PUMPELLY E AL 5 SELECTIVE INTERVAL PACKER 4 Sheets-Sheet 1 Filed Dec. 13, 1968 v ii V"l'" IlEE-iAf l Erri EJ Pay/P51. L MAE/ON 0. K/

June 30, 1970 Filed Dec. 13, 1968 R. C. PUMPELLY ETA!- SELECTIVE INTERVAL PACKER 4 sheets sheet 2 June 30, 1970 R. c. PUMPELLY ET AL 3,517,743

SELECTIVE INTERVAL PAGKER Filed Dec. 13, 1968 4 Sh'ei's-Sheet s t N Q Q Q wve/vroes P05527- CL PUMPELL June 30, 1970 R. C- PUMPELLY E AL 5 3 SELECTIVE INTERVAL PACKER Filed Dec. 13, 1968 4 Sheets-$heet INVENTOPS 14 056-97 0., PUMPELL 1 MAE/bu 0 Kgaoee HARRY a S/MPsO/v zmue United States Patent Office 3,517,743 Patented June 30, 1970 ware Filed Dec. 13, 1968, Ser. No. 783,601 Int. Cl. EZIb 33/ 1 24 US. Cl. 166-127 21 Claims ABSTRACT OF THE DISCLOSURE A selective interval packer for isolating a plurality of formations in a well bore or for isolating zones within a single formation and for selectively treating and/ or producing the isolated formations or zones. The selective interval packer includes a plurality of spaced packing elements that are deformable into sealing engagement with a well bore Wall to isolate the formations or zones, gripping means for retaining the packer in position when the packing elements are deformed, a tubular mandrel extending through the packer having a plurality of spaced seals thereon arranged to selectively isolate ports extending through the packer between the packing elements, and an indexing mechanism that permits a treating port located in the mandrel to be aligned with a selected one of the ports in the packer. The apparatus contemplates the use of a locating device such as a packer or anchor previously set in the well bore to which the selective interval packer can be releasably attached whereby the selective interval packer will be accurately positioned or located for treating the desired formations in the well bore.

BACKGROUND OF THE INVENTION The invention relates generally to packing apparatus for use in well bores. More particularly, but not by way of limitation, this invention relates to an improved packer apparatus for isolating selected formations or intervals within a formation in the well bore and testing, treating and/ or producing the selected areas.

In the completion or servicing of an oil or gas Well or the like, it is frequently desirable to be able to isolate selected areas therein and to treat the isolated areas with chemical additives or the like. For example, where a formation intersected by the well bore is made up of a loose or unconsolidated sand, it is highly desirable to be able to inject a sand consolidation material into the formation to consolidate the sand and thus prevent production of sand with the oil and/or gas into the well bore.

As is well known to those in the art of drilling wells, a well bore may penetrate a number of producing formations and each formation will have different characteristics. Thus, it is frequently desirable to be able to treat the formations individually. Also, it is well known that a single formation may have different characteristics, such as varying permeability and porosity. Therefore, it is desirable to be able to treat different portions of the same formation differently.

In the past, straddle packer type devices and othe packers having a plurality of packing elements thereon have been utilized to isolate the various areas that are to be treated. While the isolation of the various formations or intervals has been successfully accomplished, the methods and apparatus for the selective treating of the formations has not been satisfactory.

In some of the previously utilized apparatus, flow control devices have been incorporated in each of the isolated zones whereby injected materials will be either more evenly distributed to all areas or else controlled whereby they are distributed in greater quantity to one formation than the other, but all have had the common disadvantage of having the treating materials distributed to all the formations or zones isolated. None of the previously used apparatus, insofar as is known, has had the capabil- 1ty of treating a single one of the isolated formations and then being movable to selectively treat each of the remaining isolated formations.

SUMMARY OF THE INVENTION This invention provides improved well apparatus for isolating, treating and producing selected zones in a cased well bore, the apparatus includes: a hollow body member having a plurality of spaced ports therein; a plurality of spaced packing members carried by the body that are arranged to sealingly engage the casing to isolate the ports; a hollow treating member having a lateral opening there in and being movable through the hollow body member; a plurality of spaced seal members forming fluid tight seals between the treating member and the body to isolate the ports; and, an indexing device for locating the lateral opening in the treating member in communication with the ports in the body member selectively.

An object of this invention is to provide an improved selective interval packer that affectively isolates a plurality of formations or zones within a single formation in the well base whereby they can be individually treated.

Another object of the invention is to provide improved Well apparatus wherein a packer having a plurality of packing elements thereon can be accurately loated within the Well bore to isolate desired areas therein and latched in the well bore against movement whereby each of the isolated areas can be separately treated.

Still another object of the invention is to provide improved well apparatus that can be releasably latched to a locating member previously set in the well bore whereby the ports in the well apparatus will be aligned with the desired formations or zones in the Well bore.

A further object of the invention is to provide an improved well apparatus wherein a single one of a plurailty of isolated areas can be individually treated and the particular area being treated can be identified as to its location by the indexing mechanism contained within the apparatus.

The foregoing and additional objects and advantages of the invention will become more apparent as the following detailed description is read in conjunction with the accompanying drawings.

BRIEF DESCRIPTION OF THE DRAWINGS FIGS. 1A, 1B and 1C, taken together, comprise a view, partly in elevation and partly in cross-section, of a selective interval packer constructed in accordance with the invention.

FIGS. 2A, 2B and 2C, taken together, comprise a view partly in elevation and partly in cross-section, of the selective interval packer of FIGS. 1A, 1B and 1C, but show ing the packer in the set position in the well bore.

FIGS. 3, 4, 5 and 6 are enlarged schematic cross-sectional views illustrating the operation of the indexing mechanism utilized in the selective interval packer.

FIGS. 7A, 7B and 7C, taken together, comprise a view, partly in cross-section and partly in elevation, of another embodiment of the selective interval packer also constructed in accordance with the invention.

DESCRIPTION OF THE EMBODIMENT OF FIGS. 1A, 1B AND 1C Referring to the drawings and to FIGS. 1A, 1B and 1C in particular, shown therein and generally designated by the reference character 10 is a selective interval packer 3 constructed in accordance with the invention. The packer is shown positioned in a casing 12 located in a well bore (not shown).

The packer 10 is suspended on a tubing string 14 that is threadedly connected with a treating mandrel 16 by a threaded coupling 18. As shown most clearly in FIG, 1B, the treating mandrel 16 has a plurality of spaced annular seals encircling the medial portion thereof. The seals are designated by reference characters 20, 22, 24, 26, 28 and 30 beginning with the lowermost of the seals.

A treating port 32 extends laterally through the treating mandrel 16 between the seals 24 and 26. The lower end of the mandrel 16 is threadedly connected with an index mechanism body 34.

Referring again to FIG. 1A, it can'be seen that the collar 18 is connected by a shear pin 36 with a spring housing 38. The spring housing 38 encircles the mandrel 16 and carries in its lower interior a coil spring 40. The upper end of the coil spring 40 engages the spring housing 38 and the lower end thereof is in engagement with a slip sleeve 42.

The slip sleeve 42 has a flange 44 on the upper end thereof that is engageable with an inner flange 46 on the lower end of the spring housing 38. The spring 40 and the slip sleeve 42 encircle an upper portion 48 of a packer mandrel which is generally designated by the reference character 50.

The upper portion 48 of the packer mandrel 50 is threadedly connected with the spring housing 38 and the lower end thereof is threadedly connected with a medial portion 52 of the packer mandrel 50. The medial portion 52 includes an upper treating port 54 located between seals 28 and 30 and a lower treating port 56 located between seals 26 and 28. As clearly illustrated, the seals 24, 26, 28 and 30, with the packer 10 in the running-in condition as illustrated, are disposed in sealing engagement with the interior of the medial portion 52 of the packer mandrel 50. It will also be noted that the port 32 in the treating mandrel 16 is blanked off due to its position between seals 24 and 26.

The lower end of the medial portion 52 of the mandrel 50 is threadedly connected with a lower or latch portion 58. The portion 58 carries a latching device 60 near its lower end.

The latching device 60 includes an expander 62 that is connected with the lower portion 58 by shear pin 64 and a split ring slip 66 that is retained thereon between an exterior flange 68 and the expander 62. The split ring slip 66 is provided with external teeth 70 that are engageable with a locating mechanism that will be described I more fully hereinafter for positioning the packer 10 at a preselected location in the well bore. As can be appreciated, the slip 66 need not be provided with the teeth 70, but may be of any configuration that will latch into the locating mechanism. At its lower end, the lower portion 58 of the packer mandrel 50 is connected with a tubular shell 72 that forms a portion of the indexing mechanism.

Returning again to FIG. 1A, it can be seen therein that the slip sleeve 42 carries a slip housing 74 thereon. The connection between the slip housing 74 and the slip sleeve 42 is provided by a pin 76 that extends into and is movable in an elongated slot 78 formed in the slip sleeve 42. A plurality of segmented slips 80 are carried by the slip housing 74. The slips 80 are urged inwardly, that is, toward the slipsleeve 42 by a plurality of slip springs 82.

The slips 80 are retained in the slip housing by T-shaped lugs 84 that fit into mating T-shaped slots 86 in the slip housing 74. The T-lug and slot arrangement permits the slips to move radially with respect to the housing 74, but prevent longitudinal movement therebetween. The slips 80 are provided with a tapered inner surface 88 and a toothed exterior surface 90. The toothed exterior surface 90 is provided for holdingly engaging the interior wall of the casing 12 when the packer 10 is in the set position.

A plurality of the segmented expanders 92 are carried by an upper head 94. As arranged, the segmented expanders 92 can move radially relative to the upper head 94, but are prevented from moving longitudinally with respect to the longitudinal axis of the packer 10. A garter spring 96 encircles the expanders 92 biasing them rela tively inwardly toward the upper portion 48 of the packer mandrel 50. Each of the expanders 92 is provided with a tapered surface 98 that is arranged to mate with the tapered surfaces 88 on the slips 80 as will be described hereinafter.

The upper head 94 is connected by a shear pin 100 with the medial portion 52 of the packer mandrel 50. The lower end of the upper head 94 engages the uppermost of three spaced packing elements 102, 104 and 106. Disposed between the packing elements 102 and 104 is a spacer member 108 having a perforation 110 extending therethrough. A similar spacer 112 extends between the packing elements 104 and 106 and has a port 114 extending therethrough.

A lower sleeve 116 slidingly encircles the lowermost portion 58 of the packer mandrel 50. The sleeve 116 has a downwardly facing shoulder 118 thereon that is arranged to engage a locating device which will be described hereinafter. The sleeve 116 has a downwardly facing shoulder 120 near the upper end thereof that is engageable with a flange 122 carried by the packer mandrel 50.

As previously mentioned, the index mechanism body 34 is connected with the lower end of the treating mandrel 16 and the tubular shell 72 is connected with the lower end of the packer mandrel 50. These parts, along with others to be described, comprise an indexing mechanism generally designated by the reference character 124.

For convenience in manufacturing, the tubular shell 72 consists of an outer sleeve 126, a plurality of spaced annular rings or abutments 128, 130, 132, 134 and 136. The abutments are retained in the spaced relationship by a plurality of spacers 138 located therebetween.

Preferably, and as may be seen more clearly in FIG. 3, each of the abutments has an upper annular surface 140 that is disposed at an angle of approximately 45 with the horizontal and a lower annular surface 142 that is disposed at an angle of approximately 45 to the horizontal. In FIG. 3, the abutments are shown as forming an integral portion of the shell 72.

As shown in FIG. 1C, the index mechanism body 34 includes an upper annular recess 144 on the exterior thereof and a lower annular recess 146 on the exterior thereof spaced below the annular recess 144. An indexing collet 148 encircles the body 34 and has a plurality of resilient fingers 150 formed on the upper end thereof that are located in the upper annular recess 144 when the packer 10 is being lowered into the well bore. If desired, the fingers 150 could be replaced by a suitable equivalent mechanism, such as spring-loaded dogs.

The medial portion of the collet 148 is provided with a plurality of elongated slots providing resilient portions 152. Each of the resilient portions 152 is provided with an outwardly projecting lug 154. An upper surface 153 on each lug 154 is preferably disposed at an angle of approxi mately 60 to the horizontal and a lower surface 155 on each lug 154 is preferably disposed at an angle of approximately 45 to the horizontal.

The downward travel of the collet 148 on the body 34 is limited by a shear ring 156 that is threadedly attached to the body 34. The shear ring 156 is arranged to part upon the application of a predetermined load for reasons that will become more apparent hereinafter. In the event that the shear ring 156 parts, the collet 148 is retained on the body 34 by an enlargement 158 that is threadedly attached to the lower end of the body 34.

Connected with the lower end of the sleeve 72 is a valve assembly 160. The valve assembly 160 may be of any suitable type wherein the passageway through the packer 10 may be closed when desired.

As illustrated, the valve assembly 160 includes a ported retainer 162 and an annular valve seat 164 located in spaced relationship to the retainer 162. A valve ball 166 is located in the assembly 160 between the retainer 162 and the seat 164. As can be appreciated, downward movement of the packer into the well bore moves the valve ball 166 upwardly up off of the seat 164, permitting fluid to flow upwardly therethrough. However, when an attempt is made to pump fluid through the packer 10 in the downward direction, the valve ball 166 engages the seat 164, preventing flow downwardly therethrough.

OPERATION EMBODIMENT OF FIGS. 1A, 1B AND 1C FIGS. 1A, 1B and 1C, taken together, illustrate the position of the various components of the packer 10 as the packer is being lowered through the casing 12 into the well bore. As illustrated therein, the shear pin 36 prevents relative movement between the treating mandrel 16 and the spring housing 38.

The coil spring 40 exerts a downward force on the flange 44 on the upper end of the slip sleeve 42 maintaining the slip sleeve 42 in the position illustrated. The slip housing 74 will normally be in the position shown, that is, with the pin 76 located in the upper end of the slot 78 due to the resistance of liquid in the well bore as the packer 10 is lowered therethrough. However, the slot 78 is sized so that even though the slip housing 74 moves downwardly positioning the pin 76 in the lower end thereof, the slips 80 cannot engage the segmented expanders 92. Thus, the slips 80 cannot become engaged with the casing 12 and prematurely set the packer 10 as the packer 10 is lowered.

As previously described, the upper head 94 and packer mandrel are held together by the shear pin 100. The pin 100 prevents relative movement between the packer mandrel 50 and the upper head 94 which relative movement would move the expanders 92 into engagement with the slips 80.

It should also be pointed out that the indexing mechanism 124 is in the position illustrated in FIG. 1C, that is, with the lugs 154 on the collet 148 in engagement with the abutment 134 or 136. Thus, the port 32 in the treating mandrel 16 is positioned and retained in the imperforate portion of the packer mandrel 50 while lowering the packer 10 into the well bore.

Also, the valve ball 166, due to the presence of liquid in the well bore, rides upwardly off the seat 164, permitting fluid flow upwardly through the packer 10. Since the valve assembly 160 is open, the packer 10 and the tubing string 14 on which the packer 10 is being lowered, automatically fill with liquid as the packer 10 is lowered into the well bore.

The lowering of the packer 10 is continued until the downwardly facing shoulder 118 on the lower sleeve 116 engages the upper end of a locating device 167 that has been previously set in the casing 12. In FIG. 2B, the locating device 167 is illustrated as being a relatively large bore packing device of conventional construction. The

locating device 167 may be of any suitabe configuration such as an anchor or landing collar (not shown) having a bore therein and an upper end upon which the downwardly facing shoulder 118 can land.

In the locating device 167 illustrated in FIG. 2B, the lower end of the bore is provided with downwardly facing teeth 168 that are arranged to mate with the upwardly facing teeth 70 on the exterior of the latching device carried by the packer 10.

The teeth and the teeth 168 are sized dimensionally so that as the latching device 60 enters the teeth 168 there is some interference therebetween. The arrangement of the teeth permits the split ring slip 66 to ratchet downwardly until the shoulder 118 lands on the upper end of the locating device 167. When this occurs, it can be appreciated that a slight upward pull will move the expander 62 under the split ring slip 66 moving the slip 66 outwardly into firm holding engagement with the teeth 168 in the locating device 167. When the teeth 70 and 168 are engaged, the packer 10 is positively retained in the locating device 167.

It should also be pointed out that prior to running the packer 10 into the casing 12, a conventional perforating apparatus has been run therein and landed on the locating device 167. The perforating device is then actuated to form a plurality of vertically spaced perforations 170 and 172 in the casing 12. The perforations 170 and 172 (and as many other perforations as desired) extend into the formations that are to be treated. Since the formations are perforated using the locating device 167 as a reference, their precise location as related to the locating device 167 is positively known. Thus, when the packer 10 is landed on the locating 167, the packing elements 102, 104 and 106 will be in the proper locations to isolate the formations and the perforations 170 and 172.

When the shoulder 118 on the lower sleeve 116 engages the locating device 167, continued downward movement of the tubing string 14 shears the shear pin 36, moving the collar 18 downwardly until it engages the spring housing 38 which, as previously described, is threadedly connected with the packer mandrel 50. Continued downward movement of the packer mandrel 10 and spring housing 38, shears the shear pin 100 so that the packer mandrel 50 moves downwardly relative to the packing elements 102, 104 and 106 and relative to the (upper head 94 and lower sleeve 116) until the packer mandrel 50 engages the upper head 94 as shown in FIG. 2B. When this occurs, the packing elements 102 and 104 and the spacers therebetween, are moved downwardly deforming the packing elements outwardly into sealing engagement with the casing 12. At this time, the packing elements 102, 104 and 106 straddle and isolate the perforations 170 and 172 formed in the casing 12.

Simultaneously, the slip sleeve 42 is moved downwardly carrying the slip housing 74 downwardly therewith. The slips 80, which are mounted in the housing 74, also move downwardly toward the segmented expanders 92.

Prior to engagement of the slips with the expanders 92, the slip sleeve 42 moves between the expanders 92 and the packer mandrel 50, forcing the segmented expanders 92 radially outwardly positioning the segmented expanders 92 for engagement with the slips 80. When the tapered surfaces 88 on the slips 80 engage the mating tapered surfaces 98 on the expanders 92, the slips 80' are moved radially outwardly forcing the teeth thereon into holding engagement with the casing 12. At this time, the packer 10 is set in the well bore with the perforations 170 and 172 isolated. It will also be noted that the ports 54 and 56 and the ports 110 and 114 in the packer 10 are in alignment with the perforations 170 and 172 in the casing 12. The treating port 32 remains in the imperforate portion of the mandrel 50.

After the packer 10 has been set, the tubing string 14 is raised, moving the upper surface 153 on the lugs 154 of the collet 148 into engagement with the lower surface 142 on the abutment 134 as shown in FIG. 3. As continued upward movement of the tubing string 14 and the indexing device body 34 continues, the shear ring 156 moves up into engagement with the lower end of the collet 148 as shown in FIG. 4. Also as shown therein, the collet fingers on the collet 148 are moved out of the upper recess 144 and are deformed outwardly. In this position, the outside diameter of the collet fingers 150 is greater than the inner diameter of the abutments carried by the tubular shell 72.

Continued upward movement of the tubing string 14 and body 34 forces the resilient portions 152, carrying the lugs 154, inwardly into the lower recess 146 in the body 34 so that the collet 148 snaps by the abutment 134. When the collet 148 moves past the abutment 134, the

collet fingers 150, in their expanded position, engage the lower surface of the abutment 132. Since the expanded collet fingers 150 have an outer diameter greater than the inner diameter of the abutment 132, farther upward movement of the tubing string 14 and body 34 is prohibited. The treating mandrel 16 and the indexing mechanism 124 is now in the position illustrated in FIG. 2C and in FIG. 5.

As may be seen in FIG. 2B, the port 32 is now in alignment with the lower port 56 in the packer mandrel 50 and is in position to inject treating material through the aligned ports 32, 56, 114 and the perforations i170 into the formation isolated between the packing elements 104 and 106.

When it is desired to bring the port 32 into alignment with the ports 54, 110 and the perforations 172, the tubing string 14 is lowered slightly, lowering the collet 148 moves the lower surfaces 155 of the lugs 154 into engagement with the upper surface 140 of the abutment 134 as illustrated in FIG. 6. Continued downward movement of the body 34 relative to the collet 148 moves the upper recess '144 on the body 34 under the collet fingers 150 thereby permitting the collet fingers 150 to move into the upper recess 144. The collet 148 with the retracted fingers 150 will then pass the abutment 132 until the surfaces 153 on the lugs 154 engage the lower surface 142 of the abutment 132. At this time, the indexing process is performed as previously described in connection with movement past the abutment 134 so that the collet fingers 150 Will then engage the next abutment 130 bringing the treating port 32 into alignment with the ports 54, 110 and with the perforation 172. The foregoing procedure can be repeated until all of the desired formations have been treated.

The upper surfaces 153 on the lugs 154 have been provided with a greater angle relative to the horizontal than the lower surfaces 155 so that upward movement of the collet 148 past the abutments can be accomplished with less force and therefore with less chance of the collet 148 being jerked through or past more than one of the abutments at a time. The movement of the collet 148 upwardly and downwardly past the various abutments gives a positive indication at the surface of the well of the position of the indexing mechanism 124 and, thus, of the position of the treating port 32. The various indexing movements can be counted so that the precise location of the treating port 32 can be ascertained readily. In the event that the location of the port 32 is questioned, the indexing mechanism 124 can be actuated in a downward direction until the lowermost abutment has been reached and then moved upwardly while counting the steps so that it is a relatively simple matter to determine the location of the port 32.

Also, it is possible to treat any of the isolated formations when and as desired on an individual basis. While the abutments have been illustrated as being located in evenly spaced increments, the device could be provided with any desired length between abutments.

After the treating operation has been completed, the indexing mechanism 124 can be actuated to obtain a test of each of the intervals treated. For example, if the treatment performed was injecting a sand consolidation chemical, each of the intervals could be individually produced to determine whether or not sand is being produced with the oil and/or gas. Thus, the packer 10 can also be utilized in evaluating the results of the treatment performed therethrough.

After the treating operation has been performed and the intervals have been tested as desired, the tubing 14 and the treating mandrel 16 are raised upwardly until the collet 148 of the indexing mechanism 124 passes the uppermost abutment 1128. After passing the abutment 128, the tubing string 14 and treating mandrel 16 can be removed from the packer 10 and pulled to the surface o 8 the well. The remainder of the packer 10 can be left in the well bore to serve as a production packer.

If all of the formations treated are to be produced, the indexing mechanism body 34 and collet 148 are removed from the lower end of the treating mandrel 16. The treating mandrel 16 is then drilled to provide ports corresponding to each of the producing zones. A latching mechanism (not illustrated in FIGS. 1A, 1B or 1C) is connected to the lower end tubing string 14 so that when the treating mandrel 16 is replaced in the bore of the packer 10, the ports are aligned with the formations. Manifestly, if less than all of the treated formations are to be produced, the treating mandrel 16 is drilled to provide ports only in positions corresponding to the zones to be produced.

DESCRIPTION OF THE EMBODIMENT OF FIGS. 7A, 7B AND 7C FIGS. 7A, 7B and 7C, taken together, illustrate another embodiment of the selective interval packer that is generally designated by the reference character 200. It will be appreciated from comparing FIGS. 7A, 7B and 7C with FIGS. 1A, 1B and 1C that the basic components of the packer 200 are identical to those previously described in connection with the packer 10. For this reason, identical parts in the packer 200 have been designated by the same reference characters previously used in the description of the packer 10.

One of the basic dilferences between the packers 10 and 200 is in the treating mandrel 16. In the packer 200, the treating mandrel 16 is connected to a second tubing string that is disposed concentrically within the tubing string 14. It will be noted in FIG. 7B and in FIG. 7C that the shell 72 of the indexing mechanism 124 is connected to the lower portion 58 of the packer mandrel 50 in the packer 200. Also, the index mechanism body 34 of the indexing mechanism 124 is connected with the lower end of the treating mandrel 16 as it was in the packer 10.

In the embodiment of FIGS. 7A, 7B, and 7C, the lower end of the tubing string 14 is connected with a latching device 202 that is threadedly connected at its lower end to the collar 18. The collar 18 is connected with the upper end of a production tube 204. The production tube 204 extends into the packer 200 and is disposed concentrically between the packer mandrel 50 and the treating mandrel 16.

The latching mechanism 202 includes a split ring latch member 206 that is disposed in an annular recess 208 formed in the spring housing 38. With the latching mechanism 202 connected with the spring housing 38, the production tube 204 is positioned in the packer 200 with ports 210 and 212 therein located in alignment with the ports 54 and 56, respectively, in the packer mandrel 50.

The port 210 is isolated by an annular seal 214 and an annular seal 216. The seals 214 and 216 are located on each side of the port 210 in sealing relationship between the packer shell 50 and the production tube 204. Similarly, the port 212 is isolated between the annular seal 216 and an annular seal 218. The annular seal 218 is also disposed in sealing relationship between the packer shell 50 and the production tube 204.

A fourth annular seal 220 is carried by the production tube 204 and is positioned in sealing engagement with the packer mandrel 50 relatively below the imperforate portion of the packer mandrel 50 to provide for sealing the treating port 32 in the treating mandrel 16 as the packer 200 is lowered into the well bore.

Another dilference between the packer 200 and the packer 10 is in the position of the latching device 60. In the embodiment of FIGS. 1A, 1B and 10, the latching device 60 is located on the lower portion of the packer mandrel 58 in a position wherein it engages the teeth 160 on the locating mechanism 167. In the embodiment of FIGS. 7A, 7B and 70 the latching device 60 is located wholly within the lower sleeve 116 of the packer 200. As shown therein, the latching device 60 is pinned to the lower portion 58 of the packer mandrel 50 by the shear pin 64, but in a location within the lower sleeve 116.

With the arrangement shown in FIGS. 7A, 7B and 70, the entire setting operation of the packer 200 is self contained and does not depend upon a connection with the locating mechanism 167 to retain the packer mandrel 50 against upward movement. Also, it can be appreciated that if it is desired to retrieve the packer 200, an upward pull exerted thereon sufiicient to shear the pin 64 will not drop the latching device 60 into the well bore, as is true of the latching device 60 shown in the FIG. 2B location, but it will be retrieved with the lower sleeve 116.

With regard to the operation of the packer 200, the concentric tubing strings are run into the well bore with the packer 200 connected thereto until the shoulder 1-18 on the sleeve 1'16 engages the upper end of the locating device 167. When this occurs, the packer 200 is set described in connection with the packer 10. As can be appreciated by comparing FIG. 70 with FIGS. 1C and 2C, the indexing device 124 functions as previously described in connection with the packer 10.

After the treating operation has been performed, the inner tubing string, which is connected to the treating mandrel 16, is pulled upwardly from within the tubing string 14 removing the treating mandrel 16 from within the packer 200. As will be noted, the production tubing 204 is left in the packer 200 is sealed relationship to the packer mandrel 50 as previously described and the packer 200 is in condition for the well to be put into production immediately.

By providing the production tubing 204 in the construction illustrated in FIGS. 7A, 7B and 70, it is not necessary to return the modified treating mandrel 16 into the packer 200 to put the well on production as was true of the embodiment of FIGS. 1A, 1B and 10. Thus, the packer 200 eliminates the necessity for rerunning the modified treating mandrel 16 which is a relatively expensive and time consuming process.

The embodiments of the invention in which an exclusive property or privilege is claimed are defined as follows:

1. Well apparatus for isolating, treating and producing selected zones in a cased well bore, said apparatus comprising:

hollow body means having a plurality of spaced ports therein;

packing means including a plurality of spaced packing members carried by said body means, said packing members being arranged to sealingly engage the casing to isolate said ports;

a hollow treating member having a lateral opening therein, said treating member being movable through said hollow body means;

a plurality of spaced seal members forming fluid-tight seals between said treating member and body means isolating said ports; and,

index means for locating said lateral opening in said treating member in communication with the ports in said body means selectively.

2. The well apparatus of claim 1 and also including:

an elongated, tubular member disposed between said hollow body means and said treating member, said tubular member having a plurality of spaced openings therein in communication with said ports;

spaced seal members forming fluid-tight seals between said tubular member and hollow body means to isolate said ports and openings; and,

tubular member with said ports and openings in communication.

3. The well apparatus of claim 1 wherein:

said hollow body means has a plurality of spaced inwardly projecting abutments; and,

said index means includes a body member connected with the lower end of said treating member and having an annular recess therein, and

a collet member slidingly encircling said body member, said collet member having resilient collet fingers movable into and out of said annular recess, said collet member engaging one of said abutments when out of said recess to position the lateral port in said treating member in communication with one of said ports.

4. The well apparatus of claim 3 wherein:

said body member has a second annular recess spaced from said first-mentioned annular recess; and,

said collet member has a resilient medial portion and at least one lug projecting outwardly from said medial portion engageable with said spaced abutments to move said fingers out of said first-mentioned recess for engagement with said another of said abutments upon upward movement of said treating member relative to said hollow body means.

5. The well apparatus of claim 1 and also including holding means carried by said hollow body means, said holding means being movable into holding engagement with the casing to prevent movement of said apparatus relative to the casing.

6. The well apparatus of claim 5 wherein said hollow body means includes:

a first member engageable with said holding means and with said packing means; and,

a second member engageable with said packing means.

and movable with respect to said first member to deform said packing members into sealing engagement with the casing.

7. The well apparatus of claim 6 and also including locating means positioned in the well casing, said locating means engaging the second member of said packing means to permit the relative movement between said first and second members.

'8. The well apparatus of claim 7 and also including connecting means for operably connecting said first member to said locating means.

9. The well apparatus of claim 8 wherein said connecting means includes:

an expander member releasably connected to said first member; and,

gripping means carried by said first member and engageable 'with said expander member for radial movement into holding engagement with said locating means.

10. The well apparatus of claim 9 wherein:

a frangible member connects said expander member and first member, said frangible member being arranged to part when a predetermined force is exerted thereon releasing said expander member from said first member; and,

said gripping means is sized to frictionally engage said locating means prior to the radial expansion of said gripping means.

11. The well apparatus of claim 10 wherein:

said locating means has downwardly facing teeth therein; and

said gripping means has upwardly facing teeth adapted to mate with the teeth in said locating means to prevent upward movement of said first member relative to said locating means.

12. The well apparatus of claim 7 and also including connecting means for operably connecting said first and second member after deformation of said packing memlatch means connecting said hollow body means and bers.

'1 1 13. The well apparatus of claim 12 wherein said connecting means includes:

an expander member releasably connected to said first member; and,

gripping means carried by said first member and engageable with said expander member for radial movement into holding engagement with said second member.

14. The well apparatus of claim 13 wherein:

a frangible member connects said expander member and first member, said frangible member being arranged to part when a predetermined force is exerted thereon releasing said expander from said first member; and,

said gripping means is sized to frictionally engage said second member prior to the radial expansion of said gripping means.

15. The well apparatus of claim 14 wherein:

said second member has downwardly facing teeth therein and an interior flange closely encircling said first member; and,

said first member has upwardly facing teeth adapted to mate with the teeth in said first member to prevent upward movement of said first member relative to said second member.

16. In well apparatus, indexing means comprising:

a tubular member having a plurality of spaced inwardly projecting abutments;

a body member movable through said tubular member and having a recess in the exterior thereof; and

a collet member carried by said body member, said collet member including at least one resilient collet finger movable into and out of said recess, said finger engaging one of said abutments when out of said recess, and said collet member including at least one lug engageable with another of said abutments to move said finger into and out of said recess.

17. The indexing means of claim 16 wherein:

said body member has a second recess in the exterior thereof; and,

said collet member includes a resilient portion carrying said lug and positioned adjacent said second recess to permit said lug and resilient portion to move into said second recess when said finger is in said first-mentioned recess whereby said collet member can move past said first-mentioned abutment for engagement with. another of said abutments.

18. The indexing means of claim 16 wherein:

said recess is of annular configuration and said body member has a second annular recess on the exterior thereof spaced from said first-mentioned annular recess; and, wherein said collet member encircles said body member and includes a plurality of said collet fingers, each having a radially thickened end portion, said collet member also including a resilient medial portion disposed adjacent said second annular recess and having a plurality of outwardly projecting lug portions thereon arranged to sequentially engage said abutments to move said collet fingers into and out of said first-mentioned annular recess.

19. The indexing means of claim 18 wherein said resilient medial portion is provided by a plurality of circumferentially spaced longitudinal slots in said collet member.

20. The indexing means of claim 18 wherein:

each said abutment has an upwardly and outwardly tapering surface and a downwardly and outwardly tapering surface; and,

each said lug portion has a downwardly and outwardly tapering surface mating with said downwardly and outwardly tapering surface on said abutments to move said collet fingers out of said first-mentioned annular recess, and an upwardly and outwardly tapering surface mating with said upwardly and outwardly tapering surface on said abutments to move said collet member to a position wherein said fingers are disposed in said first-mentioned annular recess.

21. The indexing mechanism of claim 20 wherein said upwardly and outwardly tapering surfaces on said abutments and lug portions are at an angle relative to the longitudinal axis of said tubular member greater than the angle of said downwardly and outwardly tapering surfaces, whereby a greater force is required to move said lug portions past said abutments in a downward direction than in an, upward direction.

References Cited UNITED STATES PATENTS 3,182,726 5/1965 Stone 166-147 X 3,211,230 10/1965 Stone 166147 X 3,424,246 1/1969 Myers 166-l 27 ERNEST R. PURSER, Primary Examiner US. Cl. X.R. 166224 

